BBakken SubsurfaceNorth Dakota well index

NDIC file 32090 · API 33-025-03037-00-00

SKUNK CREEK 4-10-11-8H

Operated by DEVON ENERGY WILLISTON, L.L.C. · Dunn County, North Dakota

Active (A)Oil and gasSpud 2017

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
SOUTH FORK
Spud date
Total depth
20,330 ft
Legal location
NWNW Sec 10 T148N R93W
Footages
1,270 ft FNL · 220 ft FWL
County
Dunn County
NDIC file no.
32090
API no.
33-025-03037-00-00

Location & navigation

Navigate with Google MapsDriving directions to the well headOpen in Google MapsSatellite view of the padOpen in Apple Maps

47.65711, -102.52362

Published surface location (NAD83). A horizontal well's lateral can run up to three miles from this point.

See it in 3D

Open in the regional 3D viewerSurveyed well path, operator and production; Bakken-system horizontals onlyBakken Subsurface 3DBasin-wide production playback

Production

111 months reported, Jun 2017 to Aug 2026, BAKKEN pool.

Cumulative oil277KbblJun ’17 to Aug ’26 · 111 of 111 months known
Peak oil rate707bbl/dJul 2017 · 21,920 bbl in 31 days
Oil, last 12 months9,859bbl-26% against the 12 before
Gas–oil ratio, last 12 months1,452scf/bblfirst year 798 scf/bbl
Water cut, last 12 months54%first year 44% · 255K bbl water in all
Gas sold, last 12 months98%of gas produced · 222 mcf reported flared
0250500750Oil bbl/d27201820192020202120222023202420252026

Early time

First reported month
Jun 2017
Months to peak
2 (Jul 2017)
Peak month rate
707 bbl/d on 31 days
First 3 months, oil
34,535 bbl
First 6 months, oil
79,474 bbl
First 12 months, oil
117,559 bbl
First 24 months, oil
159,272 bbl
Share of cumulative in year 1
42%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
27 bbl/d
Latest rate as share of peak
3.8%
Uptime, last 12 months
100% of days
Cumulative gas
263K mcf
Cumulative water
255K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
7271,2621,13630241,73661%
7921,1041,15531261,39459%
9361,1171,00030311,19352%
8181,2871,10931261,57358%
7341,08780030241,48152%
6491,12682828231,73556%
9211,22284131301,32748%
8851,23094130301,39052%
8591,17785031281,37050%
8361,25192130281,49652%
8621,23390631281,43051%
8401,22287831271,45551%

As first reported to NDIC in each month's report (NDIC Monthly Production Reports, Jan 2003 to Aug 2026). Operators amend past months later and the published reports are not updated, so a month can differ from the current record. A blank or missing month is unknown, not zero, and a cumulative over such months is a lower bound; two pools reported in one month are summed. Rates per producing day divide the month's volume by the days reported, so a month reported without producing days has no rate. Gas–oil ratio is gas produced over oil produced; water cut is water over oil plus water. Months from Jan 2003 to Apr 2015 are read from the Division's PDF reports, which print no flared gas and list a well in a unitized pool only inside its unit's total.

Spacing units

Units whose published footprint holds at least 660 ft of this well's surveyed lateral. Allowances are facts extracted from signed NDIC orders, machine-extracted and not human-reviewed.

Nearby wells

Closest published well heads within 3 miles; wells on one pad share a location.

Other published attributes (1)
symbolA-OG

DMR shapefile columns not shown above, unchanged.